Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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7220/6-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7220/6-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Press release
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7220/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH0352-inline 8352 & x-line 5106
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Norsk Hydro Produksjon AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    1088-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    69
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    20.01.2005
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    29.03.2005
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    29.03.2007
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    17.09.2007
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL SHOWS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    368.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1540.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    1540.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    46
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    PRE-DEVONIAN
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 33' 12.56'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 59' 26.86'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8060886.89
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    700186.92
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5039

  • Wellbore history
    General
    Well 7220/6-1 is located on the Loppa High in the Barents Sea. The primary objective was to test reservoir properties and moveable hydrocarbons in the Permian and Carboniferous carbonates and mixed carbonates and clastics of the Gipsdalen Group (A3 prospect). Secondary objective was to evaluate the Triassic (Carnian) interval (A1 Lead), a high-risk oil leg down-flank from a major gas anomaly. The gas anomaly would not be penetrated by the well.
    Operations and results
    Wildcat well 7220/6-1 was spudded with the semi-submersible installation on 20 January 2005 and drilled to TD at 1540 m in pre-Carboniferous basement rock. The well was drilled with seawater and hi-vis pills down to 480 m, with Glydril mud from 480 m to 1130 m, with a water based bentonite mud (Drilplex) from 1130 m to 1428 m, and with Drilplex treated with Glydril from 1428 m to TD.
    The main result of well 7220/6-1 was the confirmation of the prognosed reservoir levels and the source/migration concept. The actual depths within the Triassic and Palaeozoic sections were encountered somewhat shallower than the prognosis. None of the target formations contained economical amounts of hydrocarbons. Even though the well did not prove commercial hydrocarbons, residual hydrocarbons and good oil shows were obtained in carbonates of the Gipsdalen Group, Ørn Formation from 1138 m and down to 1430 m. The gross reservoir thickness and basic lithology were as prognosed, whereas the fracture density was less than expected. Some intervals in the Paleozoic section were indicated by the logs to be source rocks (high gamma ray readings). These were analysed geochemically and found to be non-source rocks (TOC from 0.27 to 0.69 %). The whole well was thermally immature/very early mature (vitrinite reflection in the range 0.4 - 0.6 %).
    Three conventional cores were cut, covering the upper part of the Ørn Formation. The cores showed variable reservoir quality, but contained several zones with good reservoir quality and good oil shows. A total of 50 rotary sidewall cores were recovered from the well section. MDT water samples were taken at 1151.5m, 1184.5 m, 1338 m, and at 1377.1 m. Traces of oil (10 ml) was noted in the sample from 1184.5 m. The oil had, after 3 weeks exposure to atmospheric conditions, a measurable gravity of 29 deg API and was found to be mildly biodegraded.
    The well was permanently abandoned on 29 March as a dry well with shows.
    Testing
    No drill stem test was performed.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    480.00
    1537.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    1149.0
    1166.5
    [m ]
    2
    1167.0
    1197.5
    [m ]
    3
    1197.4
    1204.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    55.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    394
    476
    476
    1138
    1138
    1436
    1483

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.21

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.39
    pdf
    0.56

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX
    1123
    1537
    CMR GR
    1123
    1536
    DSI GR
    550
    1123
    FMI DSI GR
    1123
    1537
    FMI GR
    1123
    1196
    MDT
    1139
    1192
    MDT DP
    1150
    1481
    MSCT
    1205
    1485
    MWD LWD MPR DCP - RES GR
    394
    1130
    MWD LWD OTK - RES GR
    1130
    1540
    PEX
    1123
    1196
    UBI HNGS
    1123
    1534
    VSP
    729
    1503

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    391.0
    36
    0.0
    0.00
    LOT
    CONDUCTOR
    30
    454.0
    36
    454.0
    0.00
    LOT
    SURF.COND.
    20
    476.0
    26
    479.0
    1.15
    LOT
    INTERM.
    13 3/8
    543.0
    17 1/2
    546.0
    1.39
    LOT
    INTERM.
    9 5/8
    1124.0
    12 1/4
    1130.0
    2.05
    LOT
    OPEN HOLE
    1540.0
    8 1/2
    1540.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    470
    1.09
    13.0
    WATER BASED
    547
    1.09
    14.0
    WATER BASED
    664
    1.20
    14.0
    WATER BASED
    749
    1.21
    14.0
    WATER BASED
    1130
    1.21
    14.0
    WATER BASED
    1197
    1.13
    14.0
    WATER BASED
    1204
    1.13
    15.0
    WATER BASED
    1428
    1.13
    12.0
    WATER BASED
    1540
    1.20
    11.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1149.70
    [m ]
    1149.95
    [m ]
    1150.50
    [m ]
    1153.25
    [m ]
    1155.95
    [m ]
    1156.60
    [m ]
    1161.40
    [m ]
    1168.80
    [m ]
    1169.90
    [m ]
    1191.55
    [m ]
    1199.90
    [m ]
    2136.75
    [m ]
    1143.45
    [m ]
    1150.95
    [m ]
    1154.80
    [m ]
    1160.70
    [m ]
    1162.45
    [m ]
    1172.82
    [m ]
    1176.24
    [m ]
    1176.52
    [m ]
    1176.87
    [m ]
    1190.36
    [m ]
    1190.50
    [m ]
    1191.92
    [m ]
    1194.95
    [m ]
    1195.87
    [m ]
    1140.00
    [m ]
    1145.00
    [m ]
    1207.00
    [m ]
    1210.00
    [m ]
    1215.00
    [m ]
    1220.00
    [m ]
    1225.00
    [m ]
    1230.00
    [m ]
    1235.00
    [m ]
    1240.00
    [m ]
    1245.00
    [m ]
    1250.00
    [m ]
    1255.00
    [m ]
    1260.00
    [m ]
    1265.00
    [m ]
    1270.00
    [m ]
    1275.00
    [m ]
    1280.00
    [m ]
    1285.00
    [m ]
    1290.00
    [m ]
    1295.00
    [m ]
    1300.00
    [m ]
    1305.00
    [m ]
    1310.00
    [m ]
    1315.00
    [m ]
    1320.00
    [m ]
    1325.00
    [m ]
    1330.00
    [m ]
    1335.00
    [m ]
    1340.00
    [m ]
    1345.00
    [m ]
    1350.00
    [m ]
    1355.00
    [m ]
    1360.00
    [m ]
    1365.00
    [m ]
    1370.00
    [m ]
    1375.00
    [m ]
    1380.00
    [m ]
    1385.00
    [m ]
    1390.00
    [m ]
    1397.00
    [m ]
    1400.00
    [m ]
    1405.00
    [m ]
    1412.00
    [m ]
    1415.00
    [m ]
    1420.00
    [m ]
    1425.00
    [m ]
    1427.00
    [m ]
    1435.00
    [m ]
    1440.00
    [m ]
    1445.00
    [m ]
    1450.00
    [m ]
    1455.00
    [m ]
    1460.00
    [m ]
    1465.00
    [m ]
    1470.00
    [m ]
    1477.00
    [m ]
    1480.00
    [m ]
    1482.00
    [m ]
    1155.86
    [m ]
    1160.82
    [m ]
    1169.76
    [m ]
    1170.95
    [m ]
    1179.75
    [m ]
    1185.82
    [m ]
    1183.72
    [m ]
    1196.24
    [m ]
    1202.45
    [m ]

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.21